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Numerical Solution of the Multiphase Flow of Oil, Water and Gas in Horizontal Wells in Natural Petroleum Reservoirs

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Numerical Solution of the Multiphase Flow of Oil, Water and Gas in Horizontal Wells in Natural Petroleum Reservoirs Mecánica Computacional Vol XXXI, págs. 683-693 (artículo completo) Alberto Cardona, Paul H. Kohan, Ricardo D. Quinteros, Mario A. Storti (Eds.) Salta, Argentina, 13-16 Noviembre 2012 NUMERICAL SOLUTION OF THE MULTIPHASE FLOW OF OIL, WATER AND GAS IN HORIZONTAL WELLS IN NATURAL PETROLEUM RESERVOIRS Arthur B. Soprano, António F. C. da Silva and Clovis R. Maliska Mechanical Engineering Department, Federal University of Santa Catarina, 88040-900 - Florianópolis, SC, Brazil, [email protected], http://www.sinmec.ufsc.br Keywords: Drift-Flux, Newton Method, Navier-Stokes, Multiphase flow. Abstract. The estimation of oil production in natural petroleum reservoirs requires the solution of the coupled flow between the reservoir and the wellbore. The oil, water and gas flow in the well is the result of the lateral flow coming from the reservoir, obeying different completions, aiming to have an oil production with almost constant rate along the horizontal well. The multiphase flow is governed by the Navier-Stokes equations and mass conservation for each phase. Due to the large difference in spatial scales between the wellbore and the petroleum reservoir domains, the flow in the wellbore can be considered as one dimensional, taking into account, through friction models, the pressure loss caused by the lateral mass income of oil, gas and water. In this paper, the homogeneous flow model is adopted, and a slip between phases is specified accord- ing to some algebraic correlation available in the literature. The conservation equations are approximated using a finite volume method employing a staggered grid for the variable arrangement, what renders to the method robustness and guarantees a strong coupling between pressure and velocity in the wellbore. Pressures and void fractions are located at the center of the mass conservation control volume, while velocities are at the surfaces. The block-matrix is solved using a Newton-like method, with the Jacobian matrix constructed using precise numerical derivatives. Comparisons with available numerical solutions for two-phase flow are performed, showing that the model performs well and allows the use of larger time steps than the ones reported in the literature. Examples demonstrating the ability of the method for solving three-phase flows are also presented. As an overall outcome, it can be said that the developed method is suitable for taking part in a more general application for estimating oil production in petroleum reservoirs. Copyright © 2012 Asociación Argentina de Mecánica Computacional http://www.amcaonline.org.ar 684 A.B. SOPRANO, A.F.C. DA SILVA, C.R. MALISKA 1 INTRODUCTION The use of deviated wells has become an attractive alternative, since they can provide a considerable increase in production. In contrast, the high cost associated with drilling and com- pletion of wells requires a detailed study in order to find the optimal parameters for their con- struction. In deviated wells, the drilling is initially vertical and it becomes more deviated from the vertical as the depth increases until it reaches the desired final position, usually horizontal. The knowledge of flow characteristics in these wells is essential to predict the fluid dynamic behavior and define the design parameters for their construction (eg. its optimum length, diam- eter, type of completion, etc.) and for ensuring maximum production over the life of the well at a lower cost. The communication between reservoir and well is given by the well completion holes, which allow the passage of oil from the reservoir to the wells. The completion of horizontal wells is a key issue, since there is an optimum lenght for a specified pressure at the well heel.The pressure field established along the well serves as a boundary condition for the flow solution in the reservoir, modeled by Darcy equations. The reservoir and well domains are quite different, exhibiting different geometric and physical scales. In general, the well model is to be coupled with the reservoir model. Hence, it should represent the multiphase phenomenon inside the well physically consistently and need to be robust. From the technological point of view, solving the flow with broader hypotheses, as in the case of multiphase flows, has become a fundamental need for the design of these wells. If the coupled multiphase flow is solved in the well and reservoir, it is possible to study the interaction between the well and the reservoir through numerical solutions and therefore achieve a better design of the production wells. The solution of the multiphase flows can be achieved by solving the momentum conservation equations for each phase. In these models, the so-called multi-fluid models (Ishii and Hibiki, 2006), it is required to specify boundary conditions for each phase interface. Since this is an impossible task, at least with the nowadays computer resources and methods, one needs to spec- ify the interfacial mass, momentum and energy transfer, giving rise to the drag, inertial, virtual, lift and lubrication forces for closing the mathematical model. This approach, however, is too expensive when the goal is to couple the solution of the flow in the wellbore with the solution in the petroleum reservoir. In this case one should seek for a robust model with reasonable computing effort. There have been several approaches for developing a multiphase model for oil wells. Ouyang (1998) presents a very detailed review of available models and methods for dealing with each flow pattern in two-phase flow. Shi et al.(2003) proposes an approach for dealing with three- phase flow in wellbores with the usage of a drift-flux model. A compositional model has also being proposed by Shirdel and Sepehrnoori(2009) and Livescu et al.(2009) proposed a black- oil thermal model. 2 MODEL FORMULATION The physical problem consists in the solution of the one dimensional isothermal flow for each phase (gas, oil and water) on a pipe with lateral mass inflow. Therefore, pressure and velocity fields need to be solved for each phase. The Mass Conservation Equation for a phase p is given by @ (α ρ ) @ (α ρ u ) p p + p p p = q ; (1) @t @x p Copyright © 2012 Asociación Argentina de Mecánica Computacional http://www.amcaonline.org.ar Mecánica Computacional Vol XXXI, págs. 683-693 (2012) 685 where qp is a mass flux per unit volume that is associated with a possible lateral mass inflow that comes from an oil reservoir. The volumetric fraction of the phase (αp) is defined by V α = p ; (2) p V where Vp is the volume occupied by the phase and V the total volume of a control volume of interest. Additionally, by the definition of αp, we should have X αp = 1: (3) In order to couple pressure and velocities of each system, it is necessary to solve the momentum equations. Assuming the same pressure for all phases and noting that, for an advective dominant flow, diffusive flux in x direction can be neglected and the Momentum Conservation Equation for phase p becomes @ (α ρ u ) @ (α ρ u u ) @(α P ) p p p + p p p p = − p − α ρ g + F ; (4) @t @x @x p p x fp where Ffp is associated with interphase and wall forces that could affect the momentum of the system. Bonizzi and Issa(2003) presents a formulation that solves Eq. (4) with different models for Ffp depending on the multiphase flow pattern. It is important to observe that, for a gas/oil/water system, if we assume that ρp = ρp(P ), there are 7 unknowns: αg, αo, αw, ug, uo, uw and P . Since Eq. (1), Eq. (3) and Eq. (4) produce 7 equations, the problem is well posed. However, if one is interested in a faster solution of the problem, this procedure would result on a rather large non-linear system to be solved, with the extra effort of modeling complicated interphase forces in each momentum equation. Therefore, it is mandatory to reduce the number of equations, and this can de done by the use of a drift-flux model (Hibiki and Ishii, 2003). This model uses the sum of Eq. (4) for all phases and introduces a mixture velocity, defined as αgρgug + αoρouo + αwρwuw um = ; (5) ρm where ρm is the mixture density given by ρm = αgρg + αoρo + αwρw: (6) Because the drift-flux model is a two-phase model, it is necessary to somehow extend this procedure for a three-phase system. The procedure is the same as the one shown by Soprano et al.(2010), i.e., splitting the three-phase system in two sub-systems: a gas/liquid and a oil/water system, where the liquid phase is the sum of the oil and water phases. Now, it is possible to assume that the velocity of each phase in the gas/liquid system is a function of u , given by m ρ u = u + l ugl; g m ρ d m (7) αg ρg gl ul = um − ud ; αl ρm where the second parcel represents a relative velocity between the phase velocity and the mix- ture velocity. For the oil/water system, phase velocities are given as functions of ul, through the Copyright © 2012 Asociación Argentina de Mecánica Computacional http://www.amcaonline.org.ar 686 A.B. SOPRANO, A.F.C. DA SILVA, C.R. MALISKA following ρ u = u + w uow; o l ρ d l (8) αo ρo ow uw = ul − ud : αw ρl The liquid velocity is defined in a similar way as Eq. (5): αoρouo + αwρwuw ul = ; (9) ρl and ρl = αoρo + αwρw: (10) gl The term ud is a function of um and it depends on a few extra parameters. Its formula for the gas/liquid system is given by gl gl Vd + (C0 − 1) um ud = h i; (11) 1 − (C − 1) α (ρl−ρg) 0 g ρm and for the oil/water system, ow 0 ow Vd + (C 0 − 1) ul ud = h i: (12) 0 (ρo−ρw) 1 − (C 0 − 1) αo ρl Here, for the gas/liquid system, C0 is known as the profile parameter and is associated with the gl distribution of the phase along the cross-sectional area of the pipe.
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